Patent Application
20140274822
The present invention generally relates to the production of petroleum and more particularly to compositions and processes for improving the recovery of oil and gas from a subterranean geological formation.
For many years, oil and gas have been recovered from subterranean reservoirs through the use of drilled wells and production equipment. In many cases, it is desirable to utilize hydraulic fracturing techniques to improve primary and secondary recovery of oil and natural gas from the target reservoir. Hydrophilic polysaccharides and derivatized polysaccharides (such as guar gum, Carboxymethyl Hydroxypropyl Guar Gum [CMHPG], and Hydroxypropyl Guar Gum [HPG]) are often used to form viscosified carrier gels during hydraulic fracturing operations. These viscosified gel suspensions are non-Newtonian and also can be cross-linked to give very high gel strengths.
Following the well treatment operation, it is often desirable to retrieve the viscosified carrier fluids from the wellbore. To promote flowback from the well, these gel fluids can be broken to reduce the viscosity of the suspension. In many cases, “breakers” are introduced to facilitate and expedite the process of breaking the viscosified gels. The loss of viscosity is typically the result of an oxidative/reductive chemical mechanism.
The oxidative/reductive depolymerization of the polysaccharide is commonly used to reduce the viscosity of the gels. The oxidation of the polysaccharide is typically accomplished through a radical pathway in the presence of oxygen. Current oxidative type breakers frequently employ peroxide compounds slurried in a carrier fluid. The prior art carrier fluids may include certain hydrocarbons, water, polymers and/or clay-based materials.
These breaker carrier fluids suffer from several known deficiencies. First, many of these breaker carrier materials are combustible and flammable. The volatility of these carrier materials in the presence of an oxidizer necessitates special handling procedures. Second, these prior art carrier materials do not exhibit long-term stability in solution. The limited shelf life of these carrier fluids mandates that the breaker fluid be used promptly after the carrier fluid and oxidizer are mixed.
There is, therefore, a need for an improved oxidative breaker system that overcomes these and other deficiencies in the prior art.
Presently preferred embodiments of the invention include an oxidative breaker system for use in reducing the viscosity of a polysaccharide-based suspension. The oxidative breaker system preferably includes a silicone carrier fluid (preferably silicone oil), an oxidizer and a suspension aid. The suspension aid is preferably fumed silica. The oxidizer may be selected from the group consisting of alkali metal peroxide, transition metal peroxide, persulfate compounds, bromide compounds, and bromate compounds. In highly preferred embodiments, the oxidizer is magnesium peroxide or calcium peroxide.
In another aspect, preferred embodiments of the present invention include a method for reducing the viscosity of a polysaccharide-based high viscosity fluid in a downhole environment. The method includes the step of providing an oxidative breaker system, wherein the step of providing an oxidative breaker system comprises the step of mixing an oxidizer with a suspension aid in a silicone carrier fluid (preferably silicone oil). The method continues by placing the oxidative breaker system in contact with the polysaccharide-based fluid. The method also includes the step of oxidizing the polysaccharide-based fluid with the oxidative breaker system to reduce the viscosity of the polysaccharide-based fluid.
The present invention generally provides an improved oxidative breaker system for use in reducing the viscosity of polysaccharide polymer-based fluids in a downhole environment. The inventive oxidative breaker systems include a carrier fluid, a suspension aid and an oxidizer. The oxidative breaker systems can be pumped downhole to reduce the viscosity of polysaccharide polymer-based fluids used in any well treatment operation, including, but not limited to, drilling, acidizing, hydraulic fracturing, cementing and water removal operations.
The water soluble polysaccharide polymers may be any of such polymers well known in the art. See for example the book “Handbook of Water-Soluble Gums and Resins,” Robert L. Davidson, Editor, McGraw-Hill Book Co., 1980, incorporated herein by reference. Representative polymers include water soluble salts of alginic acid, carrageenan, gum agar, gum arabic, gum ghatti, gum karaya, gum tragacanth, locust bean gum, tamarind gum, cellulose derivatives such as hydroxyethyl cellulose, hydroxypropyl cellulose, carboxymethyl cellulose, hydroxyethyl carboxymethyl cellulose, and the alkyl cellulose ethers, starch ether derivatives such as carboxymethyl starch, hydroxyethyl starch, hydroxypropyl starch, and crosslinked starch ethers, guar gum and its derivatives, such as hydroxypropyl guar, hydroxyethyl guar and carboxymethyl guar, biopolymers such as xanthan gum, gellan gum, welan gum, and the like. The polysaccharide polymer is typically a cellulose ether, a starch ether which may be crosslinked, a modified guar gum, xanthan gum, gellan gum, welan gum, or mixtures thereof.
In presently preferred embodiments, the carrier fluid is preferably a silicone fluid. Suitable silicone fluids include liquid polymerized siloxanes with organic side chains, which include polydimethylsiloxanes. Suitable silicone fluids have a base viscosity of between about 50 and 1000 cSt. Particularly preferred silicone fluids include medium viscosity polydimethylsiloxanes having a base kinematic viscosity of about 350 cSt. The use of silicone fluid as a carrier fluid for an oxidative breaker system has not been recognized in the prior art. Silicone fluid has not been used in the past because of its perceived inadequacies in acting as a suspension material. The relatively high cost of silicone fluid further discourages its use in this context.
In particularly preferred embodiments, the carrier fluid is selected as a blend of octamethylcyclotetrasiloxane and decamethylcyclopentasiloxane (hereinafter “Component A”); high molecular weight cross-linked polydimethylsiloxane and octamethylcyclotetrasiloxane (hereinafter “Component B”); an 80/20 blend of Component A with Component B; 3-Hydroxypropyl-terminated polydimethyl siloxane; hydroxyalkyl-terminated polydimethyl siloxane; triacetin; polydimethylsiloxane-polyoxyethylene-polyoxypropylene copolymer (viscosity 1500-2000 cSt); polydimethylsiloxane-polyoxyethylene-polyoxypropylene copolymer (viscosity 1500-2000 cSt); polydimethylsiloxane-polyoxypropylene copolymer (viscosity <350 cSt); and trimethyl silyl terminated polydimethylsiloxane (viscosity 50-1000 cSt).
In particularly preferred embodiments, the carrier fluid is a cross-linked silicone fluid, such as an 80/20 weight percent blend of: (1) a cyclotetrasiloxane and cyclopentasiloxane combined with (2) a mixture of high molecular weight silicone elastomers (dimethicone crosspolymer) in cyclopentasiloxane.
Alternate preferred carrier fluids include carbinol endcapped silicone fluids (lower than 350 cSt), silicone-EO-PO copolymer (viscosity 1500-2000 cSt), silicone-PO copolymer (lower than 350 cSt), and silicone-EO-PO copolymer (viscosity 1500-2000 cSt).
Presently preferred suspension aids include fumed silica. In alternative embodiments, the suspension aids include fused amorphous silica, such as diatomaceous earth (DE); tallow amines, polyamide thixotropes, organic derivatives of bentonite clay, hydrated amorphous silica, a tall oil fatty acid, anionic viscosifier for drilling fluids, non-polar, high molecular weight polyisobutylene (PIB), and oligoglycerol fatty acid esters.
In yet additional alternate embodiments, the suspension aid is a tallow amine such as Ethomeen T12, a polyamide thixatrope such as Thixatrol RM, an organic derivative of bentonite clay such as Bentone 150 or Bentone 155, a polyamide Thixatrope such as Thixatrol DW 50, an hydrated amorphous silica such as Hi-Sil, a tall oil fatty acid such as Mead Westvaco's L-5, a non-polar, high molecular weight polyisobutylene such as Paratac XT, an anionic viscosifier for drilling fluids such as Polymax 1000 or aluminum oxide or emery.
Various combinations of these preferred carrier fluids and suspension aids have been found in laboratory testing to produce suspensions of varying stability. The stability of these various combination is summarized in the following table:
Preferred oxidizers are solid and include alkali or transition metal peroxides, persulfate compounds, bromide compounds, hypochlorite compounds, and bromates compounds. Particularly preferred oxidizers include magnesium peroxide and calcium peroxide. The oxidizer and suspension aids are preferably mixed together under mechanical agitation with the silicone fluid carrier fluid to prepare the oxidative breaker system.
In a first preferred embodiment, the preferred oxidative breaker system includes between about 50% and 70% by weight silicone fluid, between about 30% and 45% by weight magnesium peroxide, and between about 0% and 2% by weight fumed silica. The oxidative breaker system is preferably presented in a ratio of about 3.5 to about 5.5 pounds of magnesium peroxide per gallon of the oxidative breaker system.
In a highly preferred embodiment, the oxidative breaker system includes about 54% by weight silicone fluid, about 45% by weight magnesium peroxide and about 1% by weight fumed silica. This highly preferred embodiment is presented at a ratio of about 5 pounds of active magnesium peroxide to a gallon of the oxidative breaker system.
The oxidative breaker system optionally includes a dispersing agent. The dispersing agent can be used to accelerate the release of the oxidizer from the oxidative breaker system. Suitable dispersing agents include polydimethylsiloxane-polyalkylene oxide copolymers and polydimethyl-polyphenylmethyl-siloxane copolymers.
In a laboratory test, the first preferred embodiment of the oxidative breaker system successfully reduced the viscosity of a standard guar suspension. The oxidative breaker system was applied to a guar suspension prepared at a ratio of about 40 pounds of guar (GA-40W) to 1000 gallons of buffered tap water. The oxidative breaker system was prepared using about one pound of active magnesium peroxide to one gallon of the oxidative breaker system. The results of this test are presented in
In a second preferred embodiment, the preferred oxidative breaker system includes between about 55% and 70% by weight silicone fluid, between about 25% and 45% by weight calcium hydroxide, and between about 0% and 2% by weight fumed silica. The oxidative breaker system is preferably presented in a ratio of about 3.0 to about 5.0 pounds of calcium oxide per gallon of the oxidative breaker system.
In a highly preferred embodiment, the second preferred embodiment of the oxidative breaker system includes about 64% by weight silicone fluid, about 35.6% by weight calcium peroxide and about 0.4% by weight fumed silica. This highly preferred embodiment is presented at a ratio of about 3.73 pounds of active calcium peroxide to a gallon of the oxidative breaker system.
In a laboratory test, the second preferred embodiment of the oxidative breaker system successfully reduced the viscosity of a standard guar suspension. The oxidative breaker system was applied to a guar suspension prepared at a ratio of about 30 pounds of guar (GA-40W) to 1000 gallons of buffered tap water. The oxidative breaker system was prepared using about one pound of active calcium peroxide to one gallon of the oxidative breaker system. The results of this test are presented in the graphic in
It is clear that the present invention is well adapted to carry out its objectives and attain the ends and advantages mentioned above as well as those inherent therein. While presently preferred embodiments of the invention have been described in varying detail for purposes of disclosure, it will be understood that numerous changes may be made which will readily suggest themselves to those skilled in the art and which are encompassed within the spirit of the invention disclosed, as defined in the written description and appended claims. For example, surfactant and surfactant mixture selections can be modified and changed to take into account varying reservoir conditions.
The present application is a continuation-in-part of U.S. patent application Ser. No. 13/830,925 filed Mar. 14, 2013 entitled Oxidative Breakers in a Silicone Suspension, the disclosure of which is herein incorporated by reference.
| Number | Date | Country | |
|---|---|---|---|
| Parent | 13830925 | Mar 2013 | US |
| Child | 14055862 | US |
